U.S. patent number 6,003,607 [Application Number 08/712,758] was granted by the patent office on 1999-12-21 for wellbore equipment positioning apparatus and associated methods of completing wells.
This patent grant is currently assigned to Halliburton Energy Services, Inc.. Invention is credited to Ralph H. Echols, Karluf Hagen, Andrew Penno, Colby M. Ross.
United States Patent |
6,003,607 |
Hagen , et al. |
December 21, 1999 |
Wellbore equipment positioning apparatus and associated methods of
completing wells
Abstract
Well completion apparatus and associated methods of completing
wells provides repositioning of sand control screens and
perforating guns without requiring movement of a packer in the
wellbore. In a preferred embodiment, a well completion apparatus
has a packer, a release apparatus, a telescoping expansion joint, a
ball catcher, a sand control screen, and a perforating gun. In
another preferred embodiment, a well completion method includes the
steps of lowering a packer, release apparatus, telescoping
expansion joint, ball catcher, sand control screen, and perforating
gun into a well, perforating the wellbore casing, dispensing a
sealing ball into the release apparatus, applying pressure to
release the release apparatus, and applying pressure to expand the
telescoping joint.
Inventors: |
Hagen; Karluf (Randaberg,
NO), Ross; Colby M. (Carrollton, TX), Echols;
Ralph H. (Dallas, TX), Penno; Andrew (Olgersdorf,
AT) |
Assignee: |
Halliburton Energy Services,
Inc. (Dallas, TX)
|
Family
ID: |
24863442 |
Appl.
No.: |
08/712,758 |
Filed: |
September 12, 1996 |
Current U.S.
Class: |
166/381; 166/120;
166/318; 175/321 |
Current CPC
Class: |
E21B
17/07 (20130101); E21B 43/10 (20130101); E21B
23/04 (20130101) |
Current International
Class: |
E21B
23/04 (20060101); E21B 17/07 (20060101); E21B
17/02 (20060101); E21B 23/00 (20060101); E21B
43/02 (20060101); E21B 43/10 (20060101); E21B
023/04 (); E21B 017/07 () |
Field of
Search: |
;166/120,125,134,373,382,381 ;175/321 |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Tsay; Frank
Attorney, Agent or Firm: Herman; Paul I. Smith; Marlin
R.
Parent Case Text
CROSS-REFERENCE TO RELATED APPLICATION
This application is related to a copending application filed on
even date herewith entitled "METHODS OF COMPLETING WELLS UTILIZING
WELLBORE EQUIPMENT POSITIONING APPARATUS", attorney docket no.
HALB-950134U1, and having Colby M. Ross as the inventor thereof.
The copending application is incorporated herein by this reference.
Claims
What is claimed is:
1. Apparatus for releasably securing a first tubular member to an
overlapping and coaxially disposed second tubular member, the
apparatus comprising:
a frangible member, the frangible member releasably securing the
first tubular member against axial movement relative to the second
tubular member, such that the frangible member must be broken to
permit axial movement of the first tubular member relative to the
second tubular member;
an annular gap between the first and second tubular members;
a seal disposed in the annular gap sealingly engaging the first and
second tubular members;
a piston capable of breaking the frangible member in response to a
first predetermined pressure and axially moving the first tubular
member relative to the second tubular member after the frangible
member is broken; and
a latching profile formed on an interior surface of the first
tubular member, the latching profile being internally engageable by
a shifting tool,
whereby axial force may be applied to the first tubular member,
after engaging the shifting tool with the latching profile, to
break the frangible member and move the first tubular member
axially relative to the second tubular member.
2. The apparatus according to claim 1, further comprising a first
aperture formed on an exterior surface of the first tubular member,
and a second aperture formed on an interior surface of the second
tubular member opposite the first aperture and aligned therewith;
and wherein the frangible member comprises a shear pin extending
laterally into the first and second apertures.
3. Apparatus for releasably securing a first tubular member to an
overlapping and coaxially disposed second tubular member, the
apparatus comprising:
a frangible member, the frangible member releasably securing the
first tubular member against axial movement relative to the second
tubular member, such that the frangible member must be broken to
permit axial movement of the first tubular member relative to the
second tubular member;
an annular zap between the first and second tubular members;
a seal disposed in the annular gap sealingly engaging the first and
second tubular members; and
a piston capable of breaking the frangible member in response to a
first predetermined pressure and axially moving the first tubular
member relative to the second tubular member after the frangible
member is broken, the piston including a ball sealing surface
operatively disposed within the first tubular member, the ball
sealing surface being capable of sealingly engaging a ball, and the
ball sealing surface having an inner diameter less than an outer
diameter of the ball, and the piston further including a ball seat
capable of expanding the ball sealing surface, such that the ball
sealing surface inner diameter becomes greater than the ball outer
diameter, in response to a second predetermined pressure greater
than the first predetermined pressure.
4. Apparatus for positioning equipment in a subterranean well, the
apparatus comprising:
a telescoping member having first and second opposite ends, the
telescoping member being extendable from a first length to a second
length, the second opposite end being attached to the equipment,
the telescoping member including a first tubular member and an
overlapping and coaxially disposed second tubular member, an
annular gap between the first and second tubular members, and a
seal disposed in the annular gap sealingly engaging the first and
second tubular members;
a latch attached to the telescoping member for latching the
telescoping member at the first length, the latch being operative
to release the telescoping member for extension thereof when a
first predetermined pressure is apllied to the latch, the latch
including a frangible member securing the first tubular member
against axial movement relative to the second tubular member, such
that the frangible member must be broken to permit axial movement
of the first tubular member relative to the second tubular
member;
a hydraulic extension device attached to the telescoping member for
extending the telescoping member from the first length to the
second length after the first predetermined pressure is applied to
the latch;
an anchor, the anchor securing the telescoping member first
opposite end against longitudinal movement in the wellbore; and
an expandable ball sealing surface operatively disposed within the
first tubular member, the ball sealing surface being capable of
sealingly engaging a ball, and the ball sealing surface having an
inner diameter less than an outer diameter of the ball, such that
in response to a second predetermined pressure greater than the
first predetermined pressure the ball sealing surface inner
diameter becomes greater than the ball outer diameter,
whereby, when the first predetermined pressure is applied to the
latch, the hydraulic extension device may conveniently extend the
telescoping member to position the equipment in the wellbore.
5. Apparatus for positioning equipment in a subterranean wellbore,
the apparatus comprising:
a telescoping member having first and second opposite ends, the
telescoping member being extendable from a first length to a second
length, the first opposite end being securable against longitudinal
movement in the wellbore, and the second opposite end being
attached to the equipment;
a release mechanism attached to the telescoping member for
releasably securing the telescoping member at the first length, the
release mechanism being operative to release the telescoping member
for extension thereof when a first predetermined force is applied
to the release mechanism, the release mechanism including a
frangible member securing the telescoping member against extension
thereof, such that the frangible member must be broken to permit
extension of the telescoping member, an annular gap disposed in the
telescoping member, a seal disposed in the annular gap sealingly
engaging the first and second tubular members, and a ball sealing
surface operatively disposed within the telescoping member, the
ball sealing surface being capable of sealingly engaging a ball for
application of a first predetermined pressure thereacross, and the
ball sealing surface having an inner diameter less than an outer
diameter of the ball, such that, when the first predetermined
pressure is applied across the ball, the first predetermined force
is produced in the telescoping member, and the ball sealing surface
being expandable, such that the ball sealing surface inner diameter
becomes greater than the ball outer diameter when a second
predetermined pressure greater than the first predetermined
pressure is applied across the ball; and
a hydraulic extending piston attached to the telescoping member,
the hydraulic extending piston being operative to extend the
telescoping member from the first length to the second length after
the first predetermined force is applied to the release
mechanism,
whereby, when the first predetermined force is applied to the
release mechanism, the telescoping member may extend to position
the equipment in the wellbore.
6. Apparatus for completing a subterranean well, the apparatus
comprising:
a packer, the packer being capable of being set in the well;
first and second items of equipment; and
a force activatable telescoping member attached to the packer and
the first and second items of equipment, the telescoping member
being capable of moving the first and second items of equipment
relative to the packer while the packer is set in the well in
response to force applied to the telescoping member,
whereby the first and second items of equipment may be moved
relative to the packer by applying force to the telescoping member
while the packer is set in the well.
7. The apparatus according to claim 6, wherein:
the telescoping member comprises an expansion joint having first
and second opposite ends, the expansion joint being extendable from
a first length to a second length, the second length being greater
than the first length, a latch attached to the expansion joint and
latching the expansion joint at the first length, the latch being
operative to release the expansion joint for extension thereof when
a first predetermined pressure is applied to the latch.
8. The apparatus according to claim 7, further comprising a
hydraulic extension device attached to the telescoping member for
extending the telescoping member from the first length to the
second length after the first predetermined pressure is applied to
the latch.
9. The apparatus according to claim 7, wherein:
the telescoping member further comprises a ball having a diameter,
a tubular member having a first inner diameter, a hollow
cylindrical piston disposed in the tubular member, the piston
having an inner diameter greater than the ball diameter, a first
outer diameter slightly smaller than the tubular member first inner
diameter, and a seal for sealing between the piston first outer
diameter and the tubular member first inner diameter, a first shear
member releasably securing the piston against movement relative to
the tubular member, and a pressure activated ball release attached
to the piston, the ball release being configured to release the
ball after the piston has moved relative to the tubular member.
10. The apparatus according to claim 9, wherein:
the tubular member further comprises a polished bore receptacle
having opposite ends, one of the opposite ends being attached to
the packer, and a second inner diameter smaller than the piston
first outer diameter proximate the other of the opposite ends;
and
the piston further comprises first and second portions, the first
portion having the first outer diameter thereon and being disposed
in the tubular member between the packer and the tubular member
second inner diameter, and the second portion having a second outer
diameter smaller than the tubular member second inner diameter, the
piston second portion extending outwardly from the tubular member
and being attached to the sand control screen.
11. The apparatus according to claim 9 wherein:
the pressure activated ball release comprises a hollow cylindrical
sleeve having first and second inner diameters and an expandable
annular ring, the ring being disposed in the sleeve and having a
first inside diameter smaller than the ball diameter when disposed
in the sleeve first inner diameter and a second inside diameter
greater than the ball diameter when disposed in the sleeve second
inner diameter, the ring further having opposite ends and a ball
sealing surface on one of the opposite ends,
whereby, when the ring is disposed in the sleeve first inner
diameter, the ball may not pass through the ring but seals against
the ball sealing surface, and when the ring is disposed in the
sleeve second inner diameter, the ball is permitted to pass through
the ring.
12. The apparatus according to claim 9, wherein:
the first shear member comprises a shear pin;
the pressure activated ball release comprises a ball seat capable
of releasably capturing the ball, a ball sealing surface, the ball
sealing surface permitting pressure to be applied across the ball,
and a second shear member for releasing the ball when a second
predetermined pressure has been applied across the ball; and
the ball seat and the ball sealing surface being attached to the
sleeve such that when a first pressure differential is applied
across the ball the sleeve is biased to move from the first
position to the second position,
whereby, when the ball is captured by the ball seat and pressure is
permitted to be applied across the ball by the ball sealing
surface, the first predetermined pressure may be applied across the
ball to move the sleeve from the first position to the second
position and the piston is thereby permitted to move relative to
the tubular member, and the second predetermined pressure may be
applied across the ball to release the ball.
13. The apparatus according to claim 7, wherein:
the expansion joint comprises a first tubular member and an
overlapping and coaxially disposed second tubular member; and
the latch comprises:
a frangible member for securing the first tubular member against
axial movement relative to the second tubular member, such that the
frangible member must be broken to permit axial movement of the
first tubular member relative to the second tubular member,
an annular gap between the first and second tubular members,
and
a seal disposed in the annular gap sealingly engaging the first and
second tubular members.
14. The apparatus according to claim 13, further comprising a first
aperture formed on an exterior surface of the first tubular member,
and a second aperture formed on an interior surface of the second
tubular member opposite the first aperture and aligned therewith;
and wherein the frangible member comprises a shear pin, the shear
pin extending laterally into the first and second apertures.
15. The apparatus according to claim 13, wherein the latch further
comprises a ball sealing surface operatively disposed within the
first tubular member, the ball sealing surface being capable of
sealingly engaging a ball, the ball sealing surface having an inner
diameter less than an outer diameter of the ball, and the ball
sealing surface further being radially expandable, such that the
ball sealing surface inner diameter becomes greater than the ball
outer diameter in response to a second predetermined pressure
greater than the first predetermined pressure.
16. The apparatus according to claim 6, wherein the first item of
equipment is a perforating gun and the second item of equipment is
a sand screen.
17. A method of repositioning equipment in a subterranean well, the
method comprising the steps of:
providing an expansion joint, the expansion joint being expandable
from a first compressed position to a second expanded position
thereof;
providing a release device for securing the expansion joint in the
first compressed position until the release device is activated to
release the expansion joint for expansion to the second expanded
position thereof, the release device including a frangible member
for securing the expansion joint against expansion thereof, such
that the frangible member must be broken to permit expansion of the
expansion joint, an annular gap disposed in the expansion joint, a
seal disposed in the annular gap sealingly engaging the expansion
joint and isolating an interior flow passage within the expansion
joint from the well exterior to the expansion joint, and a ball
sealing surface operatively disposed within the expansion joint,
the ball sealing surface being capable of sealingly engaging a ball
for application of a first predetermined pressure thereacross, and
the ball sealing surface having an inner diameter less than an
outer diameter of the ball;
providing a force responsive activating device for activating the
release device to release the expansion joint;
attaching the equipment to the expansion joint;
attaching the release device to the expansion joint;
attaching the force responsive activating device to the release
device;
inserting the equipment, the expansion joint, and the force
responsive activating device into the well;
activating the activating device by applying a first predetermined
force to the activating device;
expanding the expansion joint to the second expanded position
thereof; and
expanding the ball sealing surface, such that the ball sealing
surface inner diameter is greater than the ball outer diameter, by
applying a second predetermined pressure greater than the first
predetermined pressure across the ball,
whereby, when the expansion joint is expanded to the second
expanded position thereof, the equipment is repositioned in the
well.
18. Method of completing a subterranean well, the well having a
wellbore and a formation, the formation being intersected by the
wellbore, the method comprising the steps of:
providing first and second items of equipment;
providing a pressure activatable device capable of displacing the
first and second items of equipment from a first position in which
the first item of equipment is opposite the formation to a second
position in the well, the pressure activatable device including an
expandable ball sealing surface;
attaching the first and second items of equipment to the pressure
activatable device;
inserting the first and second items of equipment and the pressure
activatable device in the well;
aligning the first item of equipment opposite the formation in the
first position;
activating the pressure activatable device to displace the first
and second items of equipment to the second position by applying a
first predetermined pressure to the pressure activatable device;
and
applying a second predetermined pressure to the pressure
activatable device to thereby expand the expandable ball sealing
surface.
19. The method according to claim 18, further comprising the steps
of:
providing a packer;
attaching the packer to the pressure activatable device;
inserting the packer in the well; and
setting the packer in the well before the step of activating the
pressure activatable device.
20. The method according to claim 18, wherein the pressure
activatable device providing step comprises the steps of:
providing a first tubular member releasably secured to an
overlapping and coaxially disposed second tubular member;
providing a frangible member;
securing the first tubular member against axial movement relative
to the second tubular member, such that the frangible means must be
broken to permit axial movement of the first tubular member
relative to the second tubular member;
providing an annular gap between the first and second tubular
members;
disposing a seal in the annular gap, the seal sealingly engaging
the first and second tubular members; and
providing a piston configured to break the frangible member in
response to the first predetermined pressure and move the first
tubular member relative to the second tubular member after the
frangible member is broken.
21. The method according to claim 20, further comprising the step
of forming a latching profile on an interior surface of the first
tubular member, the latching profile being internally engageable by
a shifting tool,
whereby axial force may be applied to the first tubular member,
after engaging the shifting tool with the latching profile, to
break the frangible member and move the first tubular member
axially relative to the second tubular member.
22. The method according to claim 20, further comprising the steps
of:
forming a first aperture on an exterior surface of the first
tubular member, and forming a second aperture on an interior
surface of the second tubular member opposite the first aperture
and aligned therewith;
and wherein the frangible member providing step comprises
installing a shear pin into the first and second apertures.
23. Wellbore equipment positioning apparatus, comprising:
an outer tubular member having upper and lower ends, and inner and
outer side surfaces;
an inner tubular member having upper and lower ends, and inner and
outer side surfaces, the inner tubular member being coaxially and
telescopingly disposed relative to the outer tubular member;
a ball catcher sealingly attached to the inner tubular member, the
ball catcher being configured for ball releasement at a first
predetermined pressure;
a fastener releasably securing the inner tubular member against
longitudinal movement relative to the outer tubular member, the
fastener releasing the inner tubular member for longitudinal
movement relative to the outer tubular member at a second
predetermined pressure, the second predetermined pressure being
less than the first predetermined pressure; and
a seal disposed between the inner tubular member and the outer
tubular member, the seal sealingly contacting the inner tubular
member outer side surface and the outer tubular member inner side
surface.
24. The apparatus according to claim 23, wherein inner tubular
member lower end extends longitudinally and outwardly from the
outer tubular member lower end, and the ball catcher is sealingly
attached to the inner tubular member lower end.
25. The apparatus according to claim 23, wherein the outer tubular
member further comprises first and second longitudinally spaced
apart radially inwardly reduced portions formed on the outer
tubular member inner side surface, and the inner tubular member
further comprises a radially outwardly enlarged portion formed on
the inner tubular member outer side surface, the radially outwardly
enlarged portion being disposed between the first and second
radially inwardly reduced portions.
26. The apparatus according to claim 23, further comprising a
shifting tool engagement profile formed on the inner tubular member
inner side surface.
27. Apparatus for positioning equipment in a subterranean well, the
apparatus comprising:
first and second telescopingly disposed tubular members;
an expandable sealing surface attached to the first tubular member;
and
a release mechanism releasably securing the first and second
tubular members against relative axial displacement
therebetween,
the release mechanism releasing the first and second tubular
members for relative displacement therebetween when a first
predetermined pressure differential is created across the
expandable sealing surface, and
the expandable sealing surface expanding when a second
predetermined pressure differential is created across the
expandable sealing surface.
28. A method of positioning equipment in a subterranean well, the
method comprising the steps of:
installing an expansion joint in a tubular string between the
earth's surface and the equipment, the expansion joint including
first and second telescopingly disposed tubular members, an
expandable sealing surface attached to the first tubular member,
and a release mechanism releasably securing the first and second
tubular members against relative axial displacement
therebetween;
creating a first predetermined pressure differential across the
expandable sealing surface, thereby releasing the release
mechanism, causing the expansion joint to axially elongate, and
repositioning the equipment in the well; and
creating a second predetermined pressure differential across the
expandable sealing surface, thereby expanding the expandable
sealing surface.
Description
BACKGROUND OF THE INVENTION
The present invention relates generally to apparatus utilized in
the completion of subterranean wells and methods of completing such
wells, and, in a preferred embodiment thereof, more particularly
provides an apparatus which facilitates the placement of sand
control screens and perforating guns opposite formations in the
wells.
In the course of completing an oil and/or gas well, it is common
practice to run a string of protective casing into the wellbore and
then to run the production tubing inside the casing. At the
wellsite, the casing is perforated across one or more production
zones to allow production fluids to enter the casing bore. During
production of the formation fluid, formation sand is also swept
into the flow path. The formation sand is typically relatively fine
sand that tends to erode production equipment in the flow path.
One or more sand screens are typically installed in the flow path
between the production tubing and the perforated casing. A packer
is customarily set above the sand screen to seal off the annulus in
the zone where production fluids flow into the production tubing.
In the past, it was usual practice to install the sand screens in
the well after the well had been perforated and the guns either
removed from the wellbore or dropped to the bottom of the well.
Well completion methods continue to utilize time and resources more
efficiently by running the guns, sand screens, and packer into the
well on the production tubing in only one trip into the well. From
the end of the production tubing down, the completion tool string
typically consists of a releasable packer (one capable of being
set, released, and reset in the casing, whether by mechanical or
hydraulic means), sand control screens, and perforating guns. The
completion string is lowered into the well until the guns are
opposite the formation to be produced, the packer is set to seal
off the annulus above the packer from the formation to be produced,
the guns are fired to perforate the casing, the packer is unset,
the completion string is again lowered until the sand screens are
opposite the perforated casing, the packer is reset, and the
formation fluids are then produced from the formation, through the
sand screens, into the production tubing, and thence to the
surface.
This method has several disadvantages, however. One disadvantage is
that a significant amount of rig time is consumed while unsetting,
repositioning, and resetting the packer. The rig operator must
typically lift the production tubing, manipulate the tubing to
unset the packer, lower the tubing into the well a predetermined
distance, manipulate the tubing to set the packer, apply tubing
weight to the packer, and, finally, perform tests to determine
whether the packer has been properly set.
Another disadvantage of the method is that the above-described
packer unsetting, repositioning, and resetting must be performed
after the casing has been perforated. A necessary consequence of
this situation is the possibility that formation fluids may enter
the wellbore, and in an extreme situation may even cause loss of
control of the well. For this reason, during the packer unsetting,
repositioning, and resetting, the well is overbalanced at the
formation during these operations--meaning that the pressure in the
wellbore is maintained at a level greater than the pressure in the
formation. This, in turn, means that wellbore fluids enter the
formation through the perforations in the casing, possibly causing
damage to the formation.
Furthermore, the method suffers from problems encountered when
attempting to reset a packer. In general, modern releasable packers
are fairly reliable when lowered into a wellbore and set in casing
at a particular location. When, however, a releasable packer is set
and then unset and moved to another location, its reliability is
greatly diminished. The slips (which grip the interior wall of the
casing) may no longer hold fast, and the packer rubbers (which seal
against the casing) may not seal adequately a second time.
Additionally, there are other circumstances where, in the drilling,
completion, rework, etc. of a well, it is necessary to reposition
equipment in the well. Frequently, in these circumstances, it is
inconvenient to reposition the equipment by manipulating tubing at
the surface, repositioning a packer, or by other methods heretofore
known. As an example, in modern practice it is common to run more
than one set of perforating guns into a well in one trip. The guns
are typically spaced apart with tubing such that each set of guns
is positioned opposite a separate formation or pay zone before the
guns are fired. If the guns could be repositioned after a first set
of guns were fired into a formation, so that a subsequent set of
guns would be positioned opposite another formation, the tubing
used to space apart the guns could be eliminated and the production
string could be shortened.
From the foregoing, it can be seen that it would be quite desirable
to provide well completion apparatus which does not require
repositioning a releasable packer, but which permits sand control
screens to be run into the well with perforating guns in one trip
and then positions the sand control screens opposite the formation
after the casing has been perforated. It is accordingly an object
of the present invention to provide such a well completion
apparatus and associated methods of completing wells.
In addition, it is desirable to provide apparatus for positioning
equipment in a wellbore. It is accordingly another object of the
present invention to provide such positioning apparatus and
associated methods of positioning equipment in a wellbore.
SUMMARY OF THE INVENTION
In carrying out the principles of the present invention, in
accordance with an embodiment thereof, well completion apparatus is
provided which may be utilized for positioning sand screens
opposite a formation after perforation of the casing, use of which
does not require the user to reposition a packer or manipulate
tubing, but which permits the sand screens and perforating guns to
be run into the well at one time.
In broad terms, wellbore equipment positioning apparatus is
provided which includes inner and outer tubular members, a ball
catcher, a fastener, and a seal. The inner and outer tubular
members each have upper and lower ends, and inner and outer side
surfaces. The inner tubular member is coaxially and telescopingly
disposed relative to the outer tubular member.
The ball catcher is sealingly attached to the inner tubular member.
The fastener releasably secures the inner tubular member against
longitudinal movement relative to the outer tubular member. The
seal is disposed between the inner tubular member and the outer
tubular member, the seal sealingly contacting the inner tubular
member outer side surface and the outer tubular member inner side
surface.
Another well equipment positioning apparatus is provided as well.
The apparatus includes inner and outer tubular members, a lug, a
tubular sleeve, a radially expandable ball seat, and first and
second fasteners.
The outer tubular member has upper and lower ends and inner and
outer side surfaces, and further has a radially outwardly extending
recess formed on its inner side surface. The inner tubular member
has upper and lower ends, and inner and outer side surfaces, and
the inner tubular member is coaxially and telescopingly disposed
relative to the outer tubular member.
The lug has inner and outer side surfaces and is attached to the
inner tubular member. The lug is aligned with the recess and is
configured for radial movement relative to the recess, the lug
outer side surface being received in the recess.
The tubular sleeve is disposed radially inwardly relative to the
lug and is longitudinally aligned with the lug. The tubular sleeve
has inner and outer side surfaces, with the tubular sleeve outer
side surface contacting the lug inner side surface.
The first fastener releasably secures the ball seat against
movement relative to the tubular sleeve, and the second fastener
releasably secures the tubular sleeve against movement relative to
the lug.
Still another wellbore equipment positioning apparatus is provided
by the present invention. The apparatus includes inner and outer
tubular members, first and second seals, a chamber, a hollow plug,
a tubular sleeve, a radially expandable ball seat, and a
fastener.
The inner and outer tubular members each have inner and outer side
surfaces and upper and lower ends. The inner tubular member is
coaxially and telescopingly disposed relative to the outer tubular
member.
The first seal sealingly engages the inner tubular member outer
side surface and the outer tubular member inner side surface. The
chamber is disposed radially between the outer tubular member inner
side surface and the inner tubular member outer side surface. The
hollow plug has a closed end extending therefrom, the plug being in
fluid communication with the chamber.
The tubular sleeve is disposed radially inwardly relative to the
plug and is longitudinally aligned with the plug, the tubular
sleeve having inner and outer side surfaces. The second seal
sealingly engages the outer side surface of the tubular sleeve and
the inner side surface of the inner tubular member. The fastener
releasably secures the ball seat against movement relative to the
tubular sleeve.
Yet another wellbore equipment positioning apparatus is provided.
The apparatus includes inner and outer tubular members, first and
second seals, a chamber, a hollow plug, a tubular sleeve, and a
ball seat.
Each of the inner and outer tubular members has inner and outer
side surfaces and upper and lower ends. The inner tubular member is
coaxially and telescopingly disposed relative to the outer tubular
member.
Each of the first and second seals sealingly engage the inner
tubular member outer side surface and the outer tubular member
inner side surface. The chamber is disposed radially between the
outer tubular member inner side surface and the inner tubular
member outer side surface. The hollow plug has a closed end
extending therefrom, and the plug is in fluid communication with
the chamber.
The tubular sleeve is disposed radially inwardly relative to the
plug and is longitudinally aligned with the plug, the tubular
sleeve having inner and outer side surfaces. The ball seat is
releasably secured against movement relative to the inner tubular
member by the plug.
Another wellbore equipment positioning apparatus is provided by the
present invention. The apparatus includes inner and outer tubular
members, first and second seals, a chamber, a hollow plug, and a
tubular sleeve.
Each of the inner and outer tubular members has inner and outer
side surfaces and upper and lower ends. The inner tubular member is
coaxially and telescopingly disposed relative to the outer tubular
member.
The first seal sealingly engages the inner tubular member outer
side surface and the outer tubular member inner side surface. The
chamber is disposed radially between the outer tubular member inner
side surface and the inner tubular member outer side surface. The
hollow plug has a closed end extending therefrom. The plug is in
fluid communication with the chamber.
The tubular sleeve is disposed radially inwardly relative to the
plug and is longitudinally aligned with the plug. The tubular
sleeve has inner and outer side surfaces and a shifting tool
engagement profile formed on the tubular sleeve inner side surface,
the tubular sleeve being releasably secured against movement
relative to the plug by the plug. The second seal is longitudinally
spaced apart from the first seal, and the second seal sealingly
engages the outer side surface of the inner tubular member and the
inner side surface of the outer tubular member.
Still another wellbore equipment positioning apparatus is provided.
The apparatus includes inner and outer tubular members, a chamber,
an opening, first and second seals, and an actuating member.
Each of the inner and outer tubular members has inner and outer
side surfaces and upper and lower ends. The outer tubular member
inner side surface has a radially enlarged portion disposed between
first and second longitudinally spaced apart radially reduced
portions formed on the outer tubular member inner side surface. The
inner tubular member is coaxially and telescopingly disposed
relative to the outer tubular member. The inner tubular member
outer side surface has a radially enlarged portion formed thereon,
and the inner tubular member outer side surface radially enlarged
portion is disposed longitudinally between the outer tubular member
inner side surface first and second radially reduced portions.
The chamber is disposed radially between the inner tubular member
outer side surface and the outer tubular member inner side surface.
The opening is in fluid communication with the chamber.
The first seal sealingly engages the outer tubular member inner
side surface first radially reduced portion and the inner tubular
member outer side surface. The second seal sealingly engages the
inner tubular member outer side surface radially enlarged portion
and the outer tubular member inner side surface.
The actuating member has an outer side surface and upper and lower
portions. The upper portion is longitudinally aligned with and
opposite the opening.
Yet another wellbore equipment positioning apparatus is provided by
the present invention. The apparatus includes inner and outer
tubular members, first, second, third, and fourth seals, a chamber,
an opening, a tubular sleeve, and a fastener.
Each of the inner and outer tubular members has inner and outer
side surfaces and upper and lower ends. The outer tubular member
inner side surface has a radially enlarged portion and
longitudinally spaced apart first and second radially reduced
portions formed thereon. The outer tubular member inner side
surface radially enlarged portion is disposed between the outer
tubular member inner side surface first and second radially reduced
portions.
The inner tubular member is coaxially and telescopingly disposed
relative to the outer tubular member. The inner tubular member
outer side surface has a radially enlarged portion and
longitudinally spaced apart first and second radially reduced
portions formed thereon. The inner tubular member outer side
surface radially enlarged portion is disposed between the inner
tubular member outer side surface first and second radially reduced
portions.
The first seal sealingly engages the inner tubular member outer
side surface radially enlarged portion and the outer tubular member
inner side surface radially enlarged portion. The second seal
sealingly engages the inner tubular member outer side surface
second radially reduced portion and the outer tubular member inner
side surface second radially reduced portion.
The chamber is disposed radially between the outer tubular member
inner side surface radially enlarged portion and the inner tubular
member outer side surface second radially reduced portion. The
opening is in fluid communication with the chamber. The tubular
sleeve is disposed radially inwardly relative to the opening and is
longitudinally aligned opposite the opening. The tubular sleeve has
inner and outer side surfaces and a shifting tool engagement
profile formed on the tubular sleeve inner side surface.
The third and fourth seals are longitudinally spaced apart. Each of
the third and fourth seals sealingly engages the tubular sleeve
outer side surface, and the third and fourth seals longitudinally
straddle the opening. The fastener releasably secures the tubular
member against movement relative to the opening.
Another wellbore equipment positioning apparatus is provided by the
present invention. The apparatus includes a generally tubular outer
assembly having an outer tubular member and an inner assembly
axially slidably received at least partially within the outer
assembly. The inner assembly includes a wellbore equipment, and the
outer tubular member at least partially outwardly surrounds the
wellbore equipment.
A release mechanism releasably secures the inner assembly against
axial displacement relative to the outer assembly. The wellbore
equipment is releasable for axial displacement relative to the
outer assembly, such that the wellbore equipment extends axially
outward from the outer assembly.
Methods of completing wells are also provided by the present
invention. A method of positioning first and second equipment
within a subterranean wellbore comprises the steps of attaching the
first and second equipment to a device having a variable axial
length; disposing the device and the first and second equipment
within the wellbore; disposing the first equipment relative to a
formation intersected by the wellbore; and varying the axial length
of the device to thereby dispose the second equipment relative to
the formation.
In another method, a wellbore equipment positioning apparatus is
disposed within a wellbore attached to a perforating gun and a sand
control screen. After a formation intersected by the wellbore has
been perforated, the apparatus is actuated to extend the apparatus
and, thereby, position the sand control screen opposite the
perforated formation.
The use of the disclosed apparatus and methods will permit rig time
to be used more efficiently. Additionally, the invention adds to
the means currently available for positioning equipment in a
well.
BRIEF DESCRIPTION OF THE DRAWINGS
FIG. 1A is a schematicized partially cross-sectional view of a
wellbore equipment positioning apparatus embodying principles of
the present invention in a compressed configuration thereof;
FIG. 1B is a schematicized partially cross-sectional view of the
apparatus illustrated in FIG. 1A in an extended configuration
thereof;
FIG. 2A is a schematicized partially cross-sectional view of a
release mechanism embodying principles of the present invention in
a secured configuration thereof;
FIG. 2B is a schematicized partially cross-sectional view of the
release mechanism illustrated in FIG. 2A in a released
configuration thereof;
FIG. 3A is a schematicized partially cross-sectional view of
another wellbore equipment positioning apparatus embodying
principles of the present invention in a compressed position
thereof;
FIG. 3B is a schematicized partially cross-sectional view of the
apparatus illustrated in FIG. 3A in an extended configuration
thereof;
FIG. 4A is a schematicized partially cross-sectional view of a
method of completing a subterranean well embodying principles of
the present invention utilizing the apparatus illustrated in FIG.
3A, here shown in a compressed configuration thereof, with a zone
to be produced being perforated;
FIG. 4B is a schematicized partially cross-sectional view of a
method of completing a subterranean well embodying principles of
the present invention utilizing the apparatus illustrated in FIG.
3A, here shown in an extended configuration thereof, with a pair of
screens positioned opposite the perforated and producing zone;
FIG. 5A is a schematicized partially cross-sectional view of yet
another wellbore equipment positioning apparatus embodying
principles of the present invention in a compressed configuration
thereof;
FIG. 5B is a schematicized partially cross-sectional view of the
apparatus illustrated in FIG. 5A in an extended configuration
thereof;
FIG. 6 is a schematicized partially cross-sectional view of yet
another wellbore equipment positioning apparatus embodying
principles of the present invention;
FIG. 7A is a schematicized partially cross-sectional view of yet
another wellbore equipment positioning apparatus embodying
principles of the present invention in a compressed configuration
thereof, and another method of completing a subterranean well
embodying principles of the present invention utilizing the
apparatus, wherein a perforating gun is positioned opposite a zone
to be perforated and produced;
FIG. 7B is a schematicized partially cross-sectional view of the
wellbore equipment positioning apparatus illustrated in FIG. 7A in
an extended configuration thereof, and the method illustrated in
FIG. 7A wherein the zone has been perforated and a screen
positioned opposite the producing zone;
FIG. 8A is a schematicized partially cross-sectional view of yet
another wellbore equipment positioning apparatus embodying
principles of the present invention in a compressed configuration
thereof;
FIG. 8B is a schematicized partially cross-sectional view of the
apparatus illustrated in FIG. 8A in an extended configuration
thereof;
FIG. 9A is a schematicized partially cross-sectional view of still
another wellbore equipment positioning apparatus embodying
principles of the present invention in a compressed configuration
thereof; and
FIG. 9B is a schematicized partially cross-sectional view of the
apparatus illustrated in FIG. 9A in an extended configuration
thereof.
DETAILED DESCRIPTION
Throughout the following description of the present invention shown
in various embodiments in the accompanying figures, the upward
direction shall be used to indicate a direction toward the top of
the drawing page and the downward direction shall be used to
indicate a direction toward the bottom of the drawing page. It is
to be understood, however, that the present invention in each of
its embodiments is operative whether oriented vertically or
horizontally, or inclined in relation to a horizontal or vertical
axis.
Illustrated in FIG. 1A is a wellbore equipment positioning
apparatus 10 which embodies principles of the present invention. As
will become apparent to those having ordinary skill in the art from
consideration of the following detailed description and
accompanying drawings, the apparatus 10 may be utilized for
positioning various types of equipment in a subterranean wellbore.
The equipment may include items such as perforating guns, sand
screens, packers, etc. The following description and drawings of
the apparatus 10, and others described herein embodying principles
of the present invention, are not intended to, and do not,
circumscribe the uses thereof contemplated by the applicants.
The apparatus 10 includes coaxial telescoping inner and outer
tubular members 14 and 12, respectively. In a preferred manner of
using the apparatus 10, an end portion 16 of outer tubular member
12 is sealingly attached to a packer (not shown in FIG. 1A) or
other means of securing the end portion 16 against axial
displacement in the wellbore. End portion 18 of inner tubular
member 14 is sealingly attached to an outer housing 20 of a
conventional ball catcher 22, an end portion 24 of which is
attached to an item of equipment (not shown in FIG. 1A). In this
manner, the apparatus 10, disposed between the packer and the
equipment, is capable of displacing the equipment axially within
the wellbore relative to the packer.
As representatively illustrated in FIG. 1A, inner and outer tubular
members 12 and 14 are coaxial and overlapping in relationship to
each other in a telescoping fashion. Radially enlarged outer
diameter 26 on inner tubular member 14 is slightly smaller in
diameter than polished inner diameter 28 of outer tubular member
12, and polished outer diameter 30 of inner tubular member 14 is
slightly smaller than radially reduced inner diameter 32 of outer
tubular member 12. This allows radially enlarged portion 34 of
inner tubular member 14 to travel longitudinally in an annular
space 36 bounded radially by inner diameter 28 and outer diameter
18 and longitudinally by radially extending internal shoulders 38
and 40 of outer tubular member 12. Internal diameter 46 of the
outer tubular member 12 is slightly larger than external diameter
52 of end portion 50 of the inner tubular member 14.
Shear pins 42, each installed in a radially extending hole 44
formed through the outer tubular member 12 and extending into
radially extending hole 48 formed radially into the inner tubular
member 14, maintain the overlapping, axially compressed,
relationship of the inner and outer tubular members, thereby
securing against axial movement of one relative to the other. The
number of shear pins 42 is selected so that a predetermined force
is necessary to shear the pins and permit inner tubular member 14
to move axially relative to outer tubular member 12. A conventional
latch profile 54 is formed in an interior bore 56 of inner tubular
member 14 so that a conventional latch member, such as a slickline
shifting tool, may latch onto the inner tubular member if
necessary, for purposes described further hereinbelow.
Interior bore 56 of inner tubular member 14 and internal diameter
46 of outer tubular member 12 form a continuous internal flow
passage 58 from end portion 16 to end portion 24 of the apparatus
10. To isolate the interior flow passage 58 from any exterior
fluids and pressures, seal 60 is disposed in a circumferential
groove 62 on the radially enlarged diameter 26. The seal 60
sealingly contacts the polished inner diameter 28 of outer tubular
member 12, and will continue to provide sealing contact therewith
if inner tubular member 14 is displaced axially relative to outer
tubular member 12. A debris seal 64, disposed in a circumferential
groove 66 formed on radially reduced inner diameter 32, is
operative to prevent debris from entering the annular space 36, but
allows fluid and pressure communication between the annular space
and the wellbore external to the apparatus 10.
Ball catcher 22, as noted above, is of conventional construction
and includes a fingered inner sleeve 68. An upper portion of the
fingered inner sleeve 68 is radially compressed into a radially
reduced inner diameter 72 of outer housing 20 and has a ball seat
70 disposed thereon. Ball seat 70 is specially designed to
sealingly engage a ball 78. In a radially enlarged inner diameter
74, the fingered inner sleeve 68 is secured against axial movement
relative to outer housing 20 by shear pins 76 extending radially
through the fingered inner sleeve and partially into the outer
housing. In the configuration representatively illustrated in FIG.
1A, the radially compressed fingered inner sleeve ball seat 70 has
an inner diameter smaller than the diameter of the ball 78.
When the ball 78 engages the ball seat 70, forming a fluid and
pressure seal therewith, pressure may be applied to the interior
flow passage 58 above the ball to create a pressure differential
across the ball, and a resulting downward biasing force, to shear
the shear pins 76 and permit the fingered inner sleeve 68 to move
axially downward relative to the outer housing 20. If the fingered
inner sleeve 68 moves a sufficient distance axially downward as
viewed in FIG. 1A, the axially compressed ball seat 70 will enter
the radially enlarged inner diameter 74 of the outer housing 20 and
expand so that its inner diameter will be larger than that of the
ball 78. When this occurs, the ball 78 is permitted to pass through
the ball catcher 22 and is therefore no longer sealingly engaged
with the ball seat 70.
It will be readily apparent to one skilled in the art that if the
pressure applied to the interior flow passage 58 is greater than
the pressure existing external to the apparatus 10, a resulting
downwardly biased axial force will also be applied to the inner
tubular member 14. If the resulting force applied to the inner
tubular member 14 exceeds the predetermined force selected to shear
the shear pins 42 securing the inner tubular member 14 against
axial movement relative to the outer tubular member 12, the shear
pins 42 will shear and the resulting force will cause the inner
tubular member 14 to move axially downward as viewed in FIG. 1A
relative to the outer tubular member 12 until the enlarged portion
34 of the inner tubular member strikes the internal shoulder 40 of
the outer tubular member. This is a preferred method of extending
the inner tubular member 14 from within the outer tubular member 12
(decreasing the length of each which overlaps the other), so that
the distance from the end portion 16 of the outer tubular member 12
to the end portion 24 of the ball catcher 22 is thereby
enlarged.
In order for the apparatus 10 to be properly configured for
operation according to the above described preferred method, the
predetermined force necessary to shear the shear pins 42 securing
the inner tubular member 14 against axial movement relative to the
outer tubular member 12 must correspond to a pressure applied to
the interior flow passage 58 above the ball 78 which is less than
the pressure required to shear the shear pins 76 securing the
fingered inner sleeve 68 against axial movement relative to the
outer housing 20.
If a circumstance should occur wherein it is not possible to extend
the apparatus 10 by applying pressure to the interior flow passage
58 to shear the shear pins 42, the shear pins 42 may alternatively
be sheared by latching a conventional shifting tool into the latch
profile 54 and applying the predetermined force downward on the
inner tubular member 14. Such a circumstance may occur, for
example, when debris prevents the sealing engagement of the ball 78
with the ball seat 70.
Turning now to FIG. 1B, the apparatus 10 of FIG. 1A is shown in its
fully extended configuration. Shear pins 42 have been sheared,
allowing the inner tubular member 14 to move axially downward as
viewed in FIG. 1B until the radially enlarged portion 34 contacts
the inner shoulder 40 of the outer tubular member 12. Movement of
the inner tubular member 14 relative to the outer tubular member 12
after the shear pins 42 are sheared may be caused by the force
resulting from the pressure applied to the interior flow passage 58
or, if the apparatus 10 is oriented at least partially vertically,
by the weight of the inner tubular member 14, ball catcher 22, and
the equipment attached thereto, or by any combination thereof.
As viewed in FIG. 1B, the shear pins 76 have also been sheared and
the fingered inner sleeve 68 has been shifted axially downward
relative to the outer housing 20 of the ball catcher 22, permitting
the ball seat 70 to expand into the enlarged diameter 74. The ball
78 is thus permitted to pass through the ball seat 70.
As described hereinabove, the pressure applied to the inner flow
passage 58 to shear the shear pins 76 in the ball catcher 22 is
greater than the pressure required to shear the shear pins 42 which
secure the inner tubular member 14 against axial movement relative
to the outer tubular member 12. Thus, as pressure is built up in
the inner flow passage 58, the shear pins 42 shear first, the inner
tubular member 14 then moves axially downward as viewed in FIG. 1B,
and then the pressure build-up continues in the inner flow passage
until the shear pins 76 in the ball catcher 22 shear, releasing the
ball 78.
Turning now to FIG. 2A, an alternative device 100 is shown for
releasably securing the inner tubular member 14 against axial
movement relative to the outer tubular member 12 in the apparatus
10. Device 100 eliminates the need for the ball catcher 22 disposed
between the end portion 18 of the inner tubular member 14 and the
equipment described hereinabove as being attached to the end
portion 24 of the ball catcher 22. Additionally, device 100
eliminates the possibility that the shear pins 42 may be sheared or
otherwise damaged while the apparatus 10 is run in the
wellbore.
Device 100 includes a circumferential groove 102 formed on the
internal diameter 46 of the outer tubular member 12. Opposite
radially extending shoulders 104 of the groove 102 are
longitudinally sloped. A plurality of complimentarily shaped lugs
or collets 106 extend radially outwardly into the groove 102. The
lugs 106 also extend radially inwardly through complimentarily
shaped apertures 108 formed through the end portion 50 of inner
tubular member 14.
Maintaining the lugs 106 in cooperative engagement with the groove
102 is a sleeve 110, an outer diameter 112 of which is in contact
with the lugs and which prevents the lugs from moving radially
inwardly. Sleeve 110 is secured against axial movement relative to
the inner tubular member 14 by radially extending shear pins 114
which extend through holes 116 in the sleeve 110 and holes 118 in
the inner tubular member 14. Thus, as long as shear pins 114 remain
intact, sleeve 110 is secured against axial movement relative to
inner tubular member 14 and lugs 106 are maintained in cooperative
engagement with groove 102, thereby securing the inner tubular
member 14 against axial movement relative to the outer tubular
member 12.
A conventional compressible ball seat 120, having on opposite ends
an upper ball sealing surface 122 and a lower radially extending
and longitudinally sloping surface 130, is radially compressed and
coaxially disposed in an inner diameter 124 of the sleeve 110.
While disposed in the inner diameter 124, the ball seat 120 remains
radially compressed, such that inner diameter 126 of the ball seat
120 and the ball sealing surface 122 is less than the diameter of
the ball 78, preventing the ball from passing axially therethrough
and permitting the ball to sealingly engage the ball sealing
surface.
The compressible ball seat 120 is maintained in the inner diameter
124 and secured against axial displacement relative to the sleeve
110 by coaxially disposed inner mandrel 128, having on opposite
ends a radially enlarged outer diameter 132 and a radially
extending and longitudinally sloping surface 134. The sloping
surface 134 is configured to complimentarily engage the radially
sloping surface 130 of the compressible ball seat 120. The inner
mandrel 128 is secured against axial movement relative to the
sleeve 110 by radially extending shear pins 114 which extend
through holes 136 formed in inner mandrel 128.
Shear pins 114 thus extend radially through holes in the inner
mandrel 128, sleeve 110, and inner tubular member 14, securing each
against axial movement relative to the others. If shear pins 114
are sheared between the inner tubular member 14 and the sleeve 110,
the sleeve is permitted to move axially downward as viewed in FIG.
2B relative to the inner tubular member until lower shoulder 138 of
sleeve 110 contacts shoulder 140 of inner tubular member 14. The
distance from shoulder 138 to shoulder 140 is sufficiently great
that if sleeve 110 moves axially downward as viewed in FIG. 2B
sufficiently far for shoulder 138 to contact shoulder 140, lugs 106
will no longer be maintained in radially outward cooperative
engagement with groove 102 by the sleeve 110. Lugs 106 will then be
permitted to move radially inward, releasing the inner tubular
member 14 for axial displacement relative to outer tubular member
12.
If shear pins 114 are sheared between the inner mandrel 128 and the
sleeve 110, the inner mandrel is permitted to move axially downward
as viewed in FIG. 2B until shoulder 142 on the inner mandrel
contacts shoulder 144 on the sleeve 110. If the inner mandrel 128
moves axially downward sufficiently far for shoulder 142 to contact
shoulder 144, the inner mandrel 128 will no longer maintain the
compressible ball seat 120 in the inner diameter 124 of the sleeve
110, and the compressible ball seat will be permitted to move
axially downward and expand into radially enlarged inner diameter
146 of the sleeve. If the compressible ball seat 120 expands into
the enlarged inner diameter 146, its inner diameter 126 will
enlarge to a diameter greater than the diameter of the ball 78,
permitting the ball to pass axially through the compressible ball
seat 120. Note that sloping surface 134, in complimentary
engagement with sloping surface 130 of the compressible ball seat
120 aids in the expansion of the compressible ball seat when it
enters the enlarged inner diameter 146 of the sleeve 110.
Inner diameter 148 of outer tubular member 12 has a polished
surface and is slightly larger than outside diameter 150 of inner
tubular member 14. A seal 152 disposed in a circumferential groove
154 formed on outside diameter 150 provides a fluid and pressure
seal between the inner and outer tubular members 14 and 12. Inner
diameter 156 of inner tubular member 14 has a polished surface and
is slightly larger than outside diameter 112 of sleeve 110. A seal
160 disposed in a circumferential groove 162 formed on outside
diameter 112 provides a fluid and pressure seal between the inner
tubular member 14 and the sleeve 110. Note that when the ball 78 is
sealingly engaged on ball sealing surface 122, and pressure is
applied to the inner flow passage 58 above the ball 78 as viewed in
FIG. 2A, a larger piston area is formed by seal 160 than is formed
by the ball sealing surface 122. Thus, as will be readily
appreciated by one skilled in the art, the resulting downwardly
biasing force borne by the shear pins 114 between the inner tubular
member 14 and the sleeve 110 is greater than the resulting force
borne by the shear pins 114 between the inner mandrel 128 and the
sleeve 110. Or, put another way, a greater pressure must be applied
to the inner flow passage 58 above the ball 78 to shear the shear
pins 114 between the sleeve 110 and the inner mandrel 128 than must
be applied to shear the shear pins 114 between the sleeve 110 and
the inner tubular member 14. of course, additional shear pins 114,
and/or larger shear pins, may be utilized to increase the pressure
required to shear the shear pins. In addition, it is not necessary
for the same shear pins 114 to secure the inner mandrel 128, sleeve
110, and inner tubular member 14 against relative axial movement,
since separate shear pins may also be utilized.
Turning now to FIG. 2B, the device 100 is shown after the shear
pins 114 have been sheared, both between the sleeve 110 and the
inner tubular member 14 and between the inner mandrel 128 and the
sleeve 110. For illustrative clarity, the inner tubular member 14
is shown as being only slightly moved axially downward relative to
the outer tubular member 12, but it is to be understood that, as
with the apparatus 10 representatively illustrated in FIG. 1B, the
inner tubular member 14, once released, may be permitted to move a
comparatively much larger distance axially relative to the outer
tubular member 12.
When ball 78 is installed in inner flow passage 58, sealingly
engaging ball sealing surface 122, and sufficient pressure is
applied to the inner flow passage above the ball, shear pins 114
shear initially between the inner tubular member 14 and the sleeve
110. The force resulting from the pressure differential across the
ball 78 moves the sleeve 110 downward, uncovering the lugs 106, and
permitting the lugs to move radially inward. The inner tubular
member 14 is thus permitted to move axially downward relative to
the outer tubular member 12. The pressure differential across the
ball 78 may then be used, if necessary, to force the inner tubular
member 14 to extend telescopically from within the outer tubular
member 12.
When the inner tubular member 14 is completely extended,
application of additional pressure to the inner flow passage 58
above the ball 78 may be used to produce a sufficient differential
pressure across the ball to shear the shear pins 114 between the
sleeve 110 and the inner mandrel 128. The differential pressure
will then force the inner mandrel 128 and compressible ball seat
120 axially downward until the compressible ball seat enters the
radially enlarged inner diameter 146 of the sleeve 110 and expands.
Sloping surface 134 on the inner mandrel 128, in contact with the
sloping surface 130 on the compressible ball seat 120, aids in
expanding the compressible ball seat 120. When the compressible
ball seat 120 has expanded into the radially enlarged inner
diameter 146, the inside diameter 126 of the ball sealing surface
122 and compressible ball seat 120 is larger than the diameter of
the ball 78, and the ball is permitted to pass axially through the
compressible ball seat 120.
Turning now to FIG. 3A, another apparatus 170 for positioning
equipment within a wellbore embodying the principles of the present
invention may be seen in a compressed configuration thereof.
Apparatus 170 includes a release mechanism 172. For convenience and
clarity of the following description of the apparatus 170 and
release mechanism 172, some elements shown in FIG. 3A have the same
numbers as those elements having substantially similar functions
which were previously described in relation to FIGS. 1A-2B.
Apparatus 170 includes outer and inner coaxial telescoping tubular
members 12 and 14, respectively. Upper end 16 of outer tubular
member 12 is secured against axial movement relative to the
wellbore by, for example, attachment to a packer set in the
wellbore, suspension from slips or an elevator on a rig, etc.
Equipment, such as screens, perforating guns, etc., is attached to
the lower end 18 of the inner tubular member 14.
An annular area 36 between a polished inside diameter 28 of the
outer tubular member 12 and a polished outer diameter 30 of the
inner tubular member 14 is substantially filled with a
substantially incompressible liquid 180, for example, oil or
silicone fluid. The annular area 36 is sealed at opposite ends by
seal 60 in groove 62 on radially enlarged portion 34 of the inner
tubular member 14 and by seal 174 in groove 176 on radially reduced
diameter portion 178 of the outer tubular member 12. In the
configuration illustrated in FIG. 3A, inner tubular member 14 is
prevented from moving axially upward relative to outer tubular
member 12 by contact between the enlarged portion 34 of the inner
tubular member 14 and an internal shoulder 38 formed in the outer
tubular member 12. Inner tubular member 14 is prevented from moving
appreciably axially downward relative to outer tubular member 12 by
the substantially incompressible liquid 180 in the annular area
36.
To permit movement of the inner tubular member 14 downward relative
to the outer tubular member 12, in order to alter the position of
the equipment in the wellbore, the liquid 180 is permitted to
escape from the annular area 36 through apertures 182 in
conventional break plugs 184. The break plugs 184 are threadedly
and sealingly installed in the inner tubular member 14 so that they
extend radially inward from the annular area 36 and through the
inner tubular member 14. The apertures 182 extend radially inward
from an end of each break plug 184 exposed to the annular area 36,
and into, but not through, an end of the break plug 184 which
extends radially inward into a circumferential groove 186 formed on
an outer diameter 188 of a sleeve 190.
As will be readily appreciated by a person of ordinary skill in the
art, if sleeve 190 moves axially downward relative to the inner
tubular member 14, thereby shearing the portions of the break plugs
184 which extend into groove 186, apertures 182 will form flow
paths for fluid communication between the annular area 36 and inner
flow passage 58. If the pressure existing in the inner flow passage
58 is greater than the pressure existing external to the apparatus
170, or if the weight of the equipment pulling downward on the
inner tubular member 14 is sufficiently great, the liquid 180 will
be forced through the apertures 182 and into the inner flow passage
58 as the annular area 36 decreases in volume. In this manner, the
inner tubular member 14 is permitted to move axially downward
relative to the outer tubular member 12.
In the release mechanism 172, the sleeve 190 is made to move
downward relative to the inner tubular member 14 to shear the break
plugs 184 by substantially the same method as that used to move the
sleeve 110 downward relative to the inner tubular member 14 to
release the lugs 106 in the release mechanism 100 illustrated in
FIGS. 2A and 2B described hereinabove. A ball 78 is installed in
sealing engagement with a ball sealing surface 122 on a
compressible ball seat 120. A seal 196 disposed in a
circumferential groove 198 formed on outside diameter 188 of the
sleeve 190 sealingly engages a polished enlarged inside diameter
200 of the inner tubular member 14. Pressure is applied to the
inner flow passage above the ball 78 so that a pressure
differential is created across the ball. The force resulting from
the differential pressure across the ball 78 pushes axially
downward on the ball seat 120, which in turn pushes axially
downward against an inner mandrel 128. The inner mandrel 128 is
restrained against axial movement relative to the sleeve 190 by
radially extending shear pins 192. When the resulting force is
sufficiently large, the break plugs 184 shear, permitting the
sleeve 190 to move axially downward relative to the inner tubular
member 14, permitting the liquid 180 in the annular area 36 to flow
through apertures 182 and into the inner flow passage 58, thereby
permitting the inner tubular member 14 to move axially downward
relative to the outer tubular member 12.
When the inner tubular member 14 has been extended fully from
within the outer tubular member 12, shoulder 194 on the inner
tubular member 14 contacts shoulder 40 on radially reduced diameter
portion 178 of the outer tubular member 12, preventing further
axially downward movement of the inner tubular member relative to
the outer tubular member. Application of additional pressure to the
inner flow passage 58 above the ball 78 is then utilized to shear
pins 192 securing inner mandrel 128 against axial movement relative
to the sleeve 190. The force resulting from this application of
additional pressure then moves the ball 78, compressible ball seat
120, and inner mandrel 128 axially downward relative to the sleeve
190 until shoulder 142 on the inner mandrel contacts shoulder 144
on the sleeve 190, permitting the compressible ball seat 120 to
enter a radially enlarged diameter 146 on the sleeve. When the
compressible ball seat 120 enters the diameter 146 it expands
radially, aided by a radially extending and longitudinally sloped
surface 134 on the inner mandrel 128 in contact with a
complimentarily sloped surface 130 on the compressible ball seat
120, such that its inside diameter 126 becomes larger than the
diameter of the ball 78. The ball 78 may then pass freely axially
through the compressible ball seat 120. Note that for the proper
sequential shearing of the break plugs 184 and shear pins 192, the
pressures applied to the inner flow passage 58 above the ball 78 to
create a pressure differential across the ball must be preselected
so that less pressure is required to shear the break plugs 184 than
to shear the shear pins 192.
Illustrated in FIG. 3B is the apparatus 170 shown in FIG. 3A in an
extended configuration thereof. The break plugs 184 have been
sheared and substantially all of the fluid 180 has escaped from the
annular area 36 into the inner flow passage 58. A radially reduced
outer diameter 202 on the sleeve 190 provides a flow path about the
sleeve.
The shear pins 192 have also been sheared, permitting the inner
mandrel 128 and compressible ball seat 120 to move axially downward
relative to the sleeve 190 and permitting the compressible ball
seat 120 to expand radially into the enlarged inside diameter 146.
Ball 78 may now pass axially through the radially expanded inside
diameter 126 of compressible ball seat 120. The inner tubular
member 14 has thus been axially extended from within the outer
mandrel 12 to alter the position in the wellbore of the equipment
attached to the lower end 18 of the inner tubular member 14.
Illustrated in FIG. 4A is a preferred method 210 of using the
apparatus 170 shown in FIGS. 3A and 3B to complete a well. The
apparatus 170, utilizing release mechanism 172 and configured in
its axially compressed configuration as shown in FIG. 3A, is
attached in a tool string 212 between a conventional packer 214 and
a pair of conventional sand screens 216.
The tool string 212 includes, in order from the bottom upward, a
pair of conventional perforating guns 218, a section of tubing 220,
the sand screens 216, another section of tubing 220, the apparatus
170, the packer 214, and further tubing 220 extending to the
surface. It is to be understood that the tool string 212 may
include other and different items of equipment for use in a
wellbore 222 which are not shown in FIG. 4A without deviating from
the principles of the present invention. It is also to be
understood that, although the tool string 212, including the
apparatus 170, is illustrated in FIG. 4A as being oriented
vertically, and the following description of the preferred method
210 refers to this vertical orientation through the use of terms
such as "upward", "downward", "above", "below", etc., the tool
string 212 may also be oriented horizontally, inclined, or
inverted, and these directional terms are used as a matter of
convenience to refer to the orientation of the tool string as
illustrated in FIG. 4A.
The tool string 212 is lowered longitudinally into the wellbore 222
from the surface until the perforating guns 218 are positioned
longitudinally opposite a potentially productive formation 224. The
packer 214 is then set in casing 226 lining the wellbore 222. As
the packer 214 is set, slips 228 bite into the casing 226 to
prevent axial movement of the tool string 212 relative to the
wellbore 222, and rubbers 230 expand radially outward to sealingly
engage the casing 226.
The perforating guns 218 are fired radially outward, forming
perforations 232 extending radially outward through the casing 226
and into the formation 224. The perforations 232 are formed so that
hydrocarbons or other useful fluids in the formation 224 may enter
the wellbore 222 for transport to the surface. Note that many
conventional methods have been developed for firing the perforating
guns 218, none of which are described herein as they are not within
the scope of the present invention.
The apparatus 170 is then extended axially as set forth in the
detailed description above in relation to FIGS. 3A and 3B. The ball
78 is installed into the release mechanism 172 and pressure is
applied to the inner flow passage 58 above the ball to shear the
break plugs 184, thus permitting the inner tubular member 14 to
move axially downward relative to the outer tubular member 12.
Additional pressure is then applied to the inner flow passage 58
above the ball 78 to shear the shear pins 192, thus permitting the
ball 78 to pass axially through the compressible ball seat 120 (see
FIGS. 3A and 3B).
FIG. 4B illustrates the method 210 of using the apparatus 170 after
the inner tubular member 14 has been axially extended from within
the outer tubular member 12. The screens 216 are now positioned
longitudinally opposite the formation 224 so that flow 234 from the
formation may pass directly through the perforations 232, into the
wellbore 222, and thence directly into the screens 216. The screens
216 filter particulate matter from the flow 234 before it enters
the tool string 212, so that the particulate matter does not clog
or damage any equipment.
Note that the ball 78 has come to rest in the section of tubing 220
between the screens 216 and the perforating guns 218. In this
position the ball 78 is not in the way of the flow 234 as it enters
the screens 216 and travels toward the surface in the inner flow
passage 58.
FIG. 5A shows an apparatus 240 for positioning equipment in a
wellbore which is another embodiment of the present invention. The
apparatus 240 is illustrated in a compressed configuration thereof.
Upper end portion 241 is preferably attached to a packer (not
shown) or other device for preventing its axial movement within the
wellbore. Lower end portion 243 is preferably attached to a single
item or multiple items of equipment, for example, tubing, sand
screen, or perforating gun. Telescoping coaxial inner and outer
tubular members, 242 and 244 respectively, are shown substantially
overlapping each other with shoulder 246 on the inner tubular
member 242 contacting shoulder 248 on the outer tubular member 244,
thereby preventing further compression of the apparatus 240.
Inner tubular member 242 is prevented from moving appreciably
axially downward relative to outer tubular member 244 by a
substantially incompressible fluid 250 contained in an annular
space 252 between the inner and outer tubular members 242 and 244.
Annular space 252 is radially bounded by a polished outer diameter
254 of the inner tubular member 242, and by a polished inner
diameter 256 of the outer tubular member 244. Annular space 252 is
longitudinally bounded by a shoulder 258 on the outer tubular
member 244, and by shoulders 260 and 262 on the inner tubular
member 242. Annular space 252 is sealed at its opposite ends by
seal 264 disposed in a circumferential groove 266 formed on a
radially enlarged portion 268 of the inner tubular member 242, and
by seal 270 disposed in a circumferential groove 272 formed on a
radially reduced portion 274 of the outer tubular member 244. Seal
264 sealingly engages inner diameter 256 of outer tubular member
244 and seal 270 sealingly engages outer diameter 254 of inner
tubular member 242.
A pair of conventional radially extending break plugs 276 having
axial apertures 278 extending partially therethrough are threadedly
and sealingly installed in threaded holes 280 extending radially
through the inner tubular member 242 between the shoulders 260 and
262. The break plugs 276 extend radially from the annular space
252, through the inner tubular member 242, and into a
circumferential groove 282 formed on an outer diameter 284 of a
ball seat 286. The aperture 278 in each break plug 276 extends from
the annular space 252 past the outer diameter 284 of ball seat 286,
so that if ball seat 286 moves axially relative to the inner
tubular member 242, thereby shearing the break plugs 276 at the
outer diameter 284, apertures 278 will form a flow path between the
annular space 252 and an inner flow passage 288 extending axially
through the inner and outer tubular members 242 and 244.
Coaxially disposed ball seat 286 is prevented from moving axially
relative to the inner tubular member 242 by the break plugs 276
which extend radially into groove 282 as described above. Ball seat
286 includes a ball sealing surface 298 disposed on a radially
extending and longitudinally sloping upper surface of the ball
seat. A seal 290 disposed in a circumferential groove 292 on outer
diameter 284 of ball seat 286 sealingly contacts a polished,
radially reduced, inner diameter 294 of the inner tubular member
242. When a ball 296 is installed in the inner flow passage 288
above the ball seat 286, a pressure differential may be created
across the ball by bringing it into sealing contact with the ball
sealing surface 298 (the ball's weight may accomplish this, or flow
may be induced in the inner flow passage to move the ball into
contact with the ball sealing surface), and applying pressure to
the inner flow passage 288 above the ball 296. A downwardly
directed axial force will result from the differential pressure
across the ball 296. The resulting downwardly directed force will
push axially downward on the ball seat 286, and be resisted by the
break plugs 276, until the break plugs shear between the inner
diameter 294 of the inner tubular member 242 and the outer diameter
284 of the ball seat.
When the break plugs 276 shear, the ball 296 and ball seat 286 are
permitted to move axially downward through the inner tubular member
242, and apertures 278 each form a flow path from the annular space
252, through the break plug 276, and into the inner flow passage
288, thereby permitting downward axial movement of the inner
tubular member 242 relative to the outer tubular member 244. The
weight of the inner tubular member 242 and the equipment attached
to the lower end portion 243 will then pull the inner tubular
member axially downward, forcing the liquid 250 through the
apertures 278 as the volume of the annular space 252 decreases.
Illustrated in FIG. 5B is the apparatus 240 of FIG. 5A in an
extended configuration thereof. Break plugs 276 have been sheared
and the ball 296 and ball seat 286 are permitted to move axially
downward through the inner tubular member 242. Substantially all of
the liquid 250 has been forced out of the annular space 252,
through the apertures 278, and into the inner flow passage 288. The
inner tubular member 242 has been forced axially downward relative
to the outer tubular member 244 until shoulder 260 contacts
shoulder 258, thereby altering the position in the wellbore of the
equipment attached to the lower end portion 243 of the inner
tubular member.
Turning now to FIG. 6, another release mechanism 306 is shown,
which may be utilized in the apparatus 240 of FIG. 5A described
hereinabove. For convenience and clarity of the following
description of the apparatus 240 and release mechanism 306, some
elements shown in FIG. 6 have the same numbers as those elements
having substantially similar functions which were previously
described in relation to FIGS. 5A and 5B.
In release mechanism 306, a sliding sleeve 308 takes the place of
the ball seat 286 shown in FIG. 5A. The sliding sleeve 308 includes
a conventional latching profile 310 formed on an inner diameter 312
thereof. Sliding sleeve 308 also includes a circumferential groove
314 formed on an outer diameter 316 thereof.
Break plugs 276 extend radially into the groove 314 and apertures
278 extend radially across the gap between inner diameter 294 of
inner tubular member 242 and outer diameter 316 of the sliding
sleeve 308. The latch profile 310 permits a conventional latching
tool (not shown) to be latched onto the sliding sleeve 308 so that
a force may be applied to the sliding sleeve to shear the break
plugs 276. The sliding sleeve 308 may be moved axially downward
through the inner tubular member 242 after the break plugs 276 have
been sheared, or may be moved axially upward through the inner flow
passage 288 by the latching tool and extracted at the surface.
As with the embodiment of the apparatus 240 shown in FIG. 5A, when
the break plugs 276 are sheared, fluid 250 in annular space 252 is
permitted to flow through the apertures 278 and into the inner flow
passage 288. The inner tubular member 242 is then permitted to move
axially downward relative to the outer tubular member 244.
Note that in the embodiment of the release mechanism 306
illustrated in FIG. 6, there is no seal on the outer diameter 316
of the sliding sleeve 308 comparable to the seal 290 on the outer
diameter 284 of the ball seat 286 illustrated in FIG. 5A. This is
because the release mechanism 306 requires no pressure differential
for its movement. For the same reason, the reduced inner diameter
294 of the inner tubular member 242 does not need to be polished in
this embodiment.
Turning now to FIG. 7A, an apparatus 326 for positioning equipment
in a subterranean wellbore 398 is illustrated installed in a tool
string 342. The apparatus 326 is shown attached at its upper end
328 to a packer 330, and at its lower end 332 to items of equipment
including a sand screen 334, gun release 336, gun firing head 338,
and perforating gun 340. The perforating gun 340, firing head 338,
and gun release 336 are conventional, other than a modification to
a portion of the gun release 336 described hereinbelow. The
illustrated gun release 336 is of the type that automatically
releases all equipment attached below an inclined muleshoe portion
344 of the gun release when the perforating gun 340 is fired by the
firing head 338.
Axially extending from the interior of an inner tubular member 348,
through bore 350 of the screen 334, to an attachment point within a
lower portion 346 of the gun release 336 is an actuating rod member
352. Lower portion 346 of the conventional gun release 336 is
modified to accept attachment of the actuating rod 352 thereto. The
actuating rod 352 is attached to the lower portion 346 of the gun
release 336 so that when the gun release releases, the actuating
rod 352 is pulled downward with the rest of the equipment.
Actuating rod 352 includes a polished cylindrical lower portion
354, which is the portion of the actuating rod which is attached to
the lower portion 346 of the gun release 336 as described above,
and a radially enlarged head portion 356, which extends coaxially
into a lower interior portion of the inner tubular member 348.
Between the bore 350 of the screen 334 and the muleshoe portion 344
of the gun release 336, the rod lower portion 354 extends axially
through a radially reduced inner diameter 358 of the screen 334.
The inner diameter 358 is slightly larger than the diameter of the
rod lower portion 354 and includes a circumferential groove 360. A
seal 362 disposed in the groove 360 sealingly engages the rod lower
portion 354.
An axial flow port 364 extends from an upper surface of the rod
head portion 356 axially downward into the head portion and
intersects a pair of axially inclined and radially extending flow
ports 366 which extend from a lower surface of the head portion.
The axial and radial flow ports 364 and 366 provide fluid and
pressure communication between the bore of the screen 350 and an
axial inner flow passage 368 in the inner tubular member 348 above
the head portion 356.
Head portion 356 is radially enlarged as compared to the rod lower
portion 354 and includes a pair of longitudinally spaced apart
circumferential grooves 370 and 372. Seals 374 and 376 are disposed
in the grooves, 370 and 372 respectively, and sealingly engage a
polished inner diameter 378 of the inner tubular member 348. Seals
374 and 376 straddle a pair of ports 380 radially extending through
the inner tubular member 348 from inner diameter 378 to a polished
outer diameter 382 of the inner tubular member. The ports 380
provide fluid communication between an annular chamber 384 and the
inner flow passage 368 when the actuating rod 352 is moved axially
downward relative to the inner tubular member 348 after the gun 340
fires and the gun release 336 releases as further described
hereinbelow.
The annular chamber 384 extends radially between the outer diameter
382 of the inner tubular member 348 and a polished inner diameter
386 of an outer tubular member 388. Outer tubular member 388 is in
a coaxial telescoping and overlapping relationship to the inner
tubular member 348. Seal 412 is disposed in a circumferential
groove 414 formed on a radially reduced upper portion 416 of the
outer tubular member 388 and is in sealing engagement with the
outer diameter 382 of the inner tubular member 348. Seal 418 is
disposed in a circumferential groove 420 formed on a lower radially
enlarged portion 422 of the inner tubular member 348 and is in
sealing engagement with the inner diameter 386 of the outer tubular
member 388.
The annular chamber 384 extends longitudinally between a shoulder
390 on the inner tubular member 348 to shoulders 392 and 394 on the
outer tubular member 388. The annular chamber 384 is substantially
filled with a substantially incompressible fluid 396, for example,
oil or silicone fluid. The fluid 396 does not permit the outer
tubular member 388 to move appreciably axially downward relative to
the inner tubular member 348, and shoulder 408 on the inner tubular
member 348, in contact with shoulder 410 on the outer tubular
member, prevents the outer tubular member from moving upward
relative to the inner tubular member. When, however, the ports 380
are no longer straddled by the seals 374 and 376, the fluid 396 may
pass from the annular chamber 384, through the ports 380, and into
the inner flow passage 368 and thereby permit the outer tubular
member 388 to move axially downward relative to the inner tubular
member 348.
FIG. 7A shows the tool string 342 positioned in the wellbore 398
with the guns 340 positioned longitudinally opposite a potentially
productive formation 400 and the packer 330 set in protective
casing 402. The function of the apparatus 326 in the illustrated
embodiment is to position the screen 334 opposite the formation 400
automatically after the gun 340 has perforated the casing 402. The
operation of the automatic gun release 336 in releasing all
equipment attached below it after the gun 340 has fired is utilized
to exert an axially downward pull on the actuator rod 352 and
thereby uncover the ports 380 so that the outer tubular member 388
is permitted to move axially downward relative to inner tubular
member 348.
FIG. 7B shows the tool string 342, including the apparatus 326,
shown in FIG. 7A in the wellbore 398 after the gun 340 has fired,
forming perforations 404 which extend radially through the casing
402 and into the formation 400. Gun release 336 has released,
permitting the lower portion 346, firing head 338, and gun 340 to
drop longitudinally downward in the wellbore 398, causing a
downward pull to be exerted on the lower portion 354 of the
actuating rod 352.
Due to the downward pull on the actuating rod 352, head portion 356
has been moved axially downward such that it is no longer in the
interior of the inner tubular member 348, but is in a lower portion
of the bore 350 of the screen 334. Seals 374 and 376 no longer
straddle the ports 380, therefore, fluid communication has been
established between the annular chamber 384 and the inner flow
passage 368. Substantially all of the fluid 396 has been forced out
of the annular chamber 384 due to the annular chamber's decreased
volume.
Shoulder 392 contacts shoulder 390, preventing further axially
downward movement of the outer tubular member 388 relative to the
inner tubular member 348. In the extended configuration of the
apparatus 326 illustrated in FIG. 7B, the screen 334 is now
positioned longitudinally opposite the formation 400 and formation
fluids 406 may now flow directly from the formation, through the
perforations 404, and into the bore 350 of the screen 334. Note
that the screen 334 was positioned opposite the formation 400,
displacing the gun 340, automatically after the gun was fired.
It is to be understood that although FIG. 7B shows the rod lower
portion 354 remaining attached to the gun release lower portion
346, the rod lower portion 354 may be detached from the gun release
lower portion 346, thereby allowing the gun 340, firing head 338,
and gun release lower portion 346 to drop to the bottom of the
wellbore 398, without deviating from the principles of the present
invention. It is also to be understood that the rod lower portion
354 may be detached from the rod head portion 356 after the gun
release 336 has released, thereby allowing the rod lower portion
354 to drop to the bottom of the wellbore 398 along with the gun
340, firing head 338, and gun release lower portion 346 without
deviating from the principles of the present invention.
Illustrated in FIG. 8A is an apparatus 430 for positioning
equipment in a wellbore. The apparatus 430 includes inner and outer
coaxial telescoping tubular members, 432 and 434 respectively. As
shown in FIG. 8A, the apparatus 430 is configured in an axially
compressed position wherein the outer tubular member 434
substantially overlaps the inner tubular member 432. In the
compressed position, the distance between upper end portion 436 and
lower end portion 438 of the apparatus 430 is minimized. The upper
end portion 436 is preferably attached to a device for preventing
axial movement of the apparatus 430 in the wellbore, such as a
packer, and lower end portion 438 is preferably attached to the
equipment. Shoulder 440 on the outer tubular member 434, in contact
with shoulder 442 on the inner tubular member 432, prevents further
axial compression of the apparatus 430.
Axial flow passage 444 extends through the apparatus 430 providing
fluid and pressure communication between the upper end portion 436
and the lower end portion 438. A tubular sliding sleeve 446 axially
disposed within the flow passage 444 is secured to the inner
tubular member 432 by means of shear pins 448. Each of the shear
pins 448 are installed in holes 450, which extend radially through
the sliding sleeve 446, and holes 452, which extend radially into,
but not through, the inner tubular member 432. A conventional
latching profile 454 is formed on inner diameter 456 of the sliding
sleeve 446, so that a conventional latching tool (not shown) may be
latched into the latching profile 454 in order to apply a
predetermined axial force to the shifting sleeve 446 to shear the
shear pins 448.
Seals 458 and 460 are disposed in longitudinally spaced apart
circumferential grooves, 462 and 464 respectively, formed on outer
diameter 466 of the sliding sleeve 446, and sealingly engage a
polished inner diameter 468 of the inner tubular member 432. Seals
458 and 460 straddle ports 470 and prevent fluid communication
between the ports and the flow passage 444. Ports 470 extend
radially through the inner tubular member 432 from inner diameter
468 to a polished outer diameter 472 of the inner tubular
member.
The ports 470 are in fluid communication with an annular chamber
474. The annular chamber 474 extends radially from outer diameter
472 of the inner tubular member 432 to a polished inner diameter
476 of the outer tubular member 434. The annular chamber 474
extends longitudinally from shoulder 478 on a radially enlarged
portion 480 of inner tubular member 432 to radially extending and
longitudinally sloping shoulder 482 on the outer tubular member
434. A substantially inexpandable fluid 484 substantially fills the
annular chamber 474.
Seal 486, disposed in circumferential groove 488 formed on the
radially enlarged portion 480 of the inner tubular member 432,
sealingly contacts the inner diameter 476 of the outer tubular
member 434. Seal 490, disposed in circumferential groove 492 formed
on radially reduced portion 494 of the outer tubular member 434,
sealingly contacts the outer diameter 472 of the inner tubular
member 432.
The outer tubular member 434 is not permitted to move appreciably
axially downward relative to the inner tubular member 432 because
such movement would require an increase in the volume of the
annular chamber 474. Since the annular chamber 474 is sealed and
the fluid 484 therein is substantially inexpandable, the volume of
the annular chamber cannot be appreciably increased. When, however,
the shear pins 448 are sheared and the sliding sleeve 446 is
axially displaced such that seals 458 and 460 no longer straddle
the ports 470, the annular chamber 474 is in fluid communication
with the flow passage 444 and fluid may enter the annular chamber
474 so that it is permitted to expand.
FIG. 8B shows the apparatus 430 illustrated in FIG. 8A in an
extended configuration thereof. A conventional latching or shifting
tool (not shown) has been latched into the latching profile 454 in
the sliding sleeve 446 and the predetermined forced applied to
shear the shear pins 448 and move the sliding sleeve axially upward
so that seals 458 and 460 no longer straddle the ports 470.
Fluid communication has been established between the flow passage
444 and the ports 470, thereby permitting the annular chamber 474
to expand volumetrically. Outer diameter 472 of inner tubular
member 432 is no longer within the reduced portion 494 of the outer
tubular member 434, therefore, the outer diameter 472 no longer
forms a boundary of the annular chamber 474 and the annular chamber
essentially ceases to exist.
The outer tubular member 434 is permitted to move axially downward
relative to the inner tubular member 432 until shoulder 496 on the
outer tubular member contacts shoulder 498 on the inner tubular
member. The equipment attached to the lower end portion 438 is,
thus, moved longitudinally downward in the wellbore relative to the
upper end portion 436 of the apparatus 430.
Turning now to FIG. 9A, a wellbore equipment positioning apparatus
500 embodying principles of the present invention is
representatively illustrated. As shown in FIG. 9A, the apparatus
500 is in its compressed configuration, a tubular and axially
extending sand control screen 502 being telescopingly disposed
within an outer axially extending tubular member 504. Thus, with
the apparatus 500 in its compressed configuration, the screen 502
is radially outwardly overlapped by the tubular member 504.
The screen 502 forms a portion of an inner axially extendable
tubular assembly 506. Other components of the inner assembly 506
include a releasing sleeve 508, a stop ring 510, an upper mandrel
512, a ball seat 514, and a lower mandrel 516. The screen 502,
releasing sleeve 508, upper mandrel 512, and lower mandrel 516 are
threadedly attached to each other.
The outer tubular member 504 likewise forms a portion of an outer
tubular assembly 518. Other components of the outer assembly 518
include a releasing head 520, a threaded collar 522, and a lower
retainer 524. The outer tubular member 504, releasing head 520,
collar 522, and lower retainer 524 are threadedly attached to each
other.
In a preferred construction of the apparatus 500, the releasing
head 520 is internally threaded for attachment to production tubing
526 (e.g., conventional 31/2" NU tubing), and is externally
threaded for attachment to the collar 522. In the preferred
construction, the collar 522 is a conventional 7" casing collar,
the outer tubular member 504 is a conventional 7" casing, and the
lower retainer 524 is a modified conventional 7" casing shoe.
In its compressed configuration, the apparatus 500 affords
protection to the screen 502 disposed within the outer assembly
518. Thus, when the apparatus 500 is run into a wellbore, for
example, suspended from tubing 526, debris, paraffin, etc. in the
wellbore is prevented from contacting the screen 502 by the outer
assembly 518 outwardly surrounding the inner assembly 506. In
another manner of using the apparatus 500, after the apparatus has
been placed in its extended configuration as shown in FIG. 9B, the
outer assembly 518 may be lowered to again outwardly surround the
inner assembly 506, so that remedial operations, such as screen
washing, may be performed with the screen 502 protected by the
outer assembly 518.
The lower mandrel 516 is axially slidably disposed within the lower
retainer 524. A polished outer surface 528 of the lower mandrel 516
is sealingly engaged by seals 530 internally carried on the lower
retainer 524. This sealing engagement prevents fluid communication
between the wellbore and the interior 532 of the apparatus 500.
The apparatus 500 is maintained in its compressed configuration by
cooperative engagement between a series of circumferentially spaced
apart balls 534 and an internally formed groove 536 on the
releasing head 520. The balls 534 extend radially through holes 538
formed radially through the releasing sleeve 508, and are outwardly
supported by the ball seat 514.
The ball seat 514 is maintained in its position radially aligned
with the balls 534 by a shear screw 540 threadedly installed
radially through the releasing sleeve 508 and into the ball seat.
Note that the shear screw 540 is installed through a hole 542
formed radially through the releasing head 520. Thus, the balls 534
prevent relative axial displacement between the releasing sleeve
508 and the releasing head 520, and the shear screw 540 prevents
relative axial displacement between the ball seat 514 and the
releasing sleeve.
A seal 544 internally carried on the releasing head 520 sealingly
engages the releasing sleeve 508, and a seal 546 internally carried
on the releasing sleeve 508 sealingly engages the ball seat 514.
The ball seat 514 has an upper inclined ball seal surface 548
formed thereon for sealing engagement with a ball 550 (see FIG.
9B). When it is desired to axially outwardly extend the inner
assembly 506 from within the outer assembly 518, the ball 550 may
be dropped through the tubing 526 at the earth's surface, so that
the ball sealingly engages the ball seal surface 548. Fluid
pressure may then be applied to the tubing 526 at the earth's
surface to shear the shear screw 540, thereby permitting the ball
550 and ball seat 514 to be axially downwardly displaced relative
to the releasing sleeve 508 and permitting the balls 534 to
radially inwardly disengage from the groove 536.
Referring additionally now to FIG. 9B, the apparatus 500 is
representatively illustrated in its extended configuration. The
ball 550 has sealingly engaged the ball seal surface 548, and the
shear screw 540 has been sheared by application of pressure to the
tubing 526. The ball and ball seat 514 are now disposed adjacent
the lower mandrel 516.
The axially downward displacement of the ball seat 514 relative to
the releasing sleeve 508 has permitted the balls 534 to radially
inwardly displace and disengage from the groove 536. Thus, the
releasing sleeve 508 and the remainder of the inner assembly 506
have been permitted to axially downwardly displace relative to the
releasing head 520 and the remainder of the outer assembly 518.
Note that the screen 502 is now exposed to the wellbore and is in
an advantageous position for screening production fluids flowing
from the wellbore to the interior 532 of the apparatus 500 and
through the tubing 526 to the earth's surface.
In the extended configuration of the apparatus 500 as
representatively illustrated in FIG. 9B, the inner assembly 506 is
prevented from further axially downward displacement relative to
the outer assembly 518 by the stop ring 510 externally disposed on
the upper mandrel 512. The stop ring 510 is secured to the upper
mandrel 512 by a shear pin 552 installed radially through the stop
ring and into the upper mandrel 512. The stop ring 510 is radially
enlarged relative to a bore 554 formed axially through the lower
retainer 524.
If it should become desirable to retrieve the outer assembly 518
from the wellbore without also retrieving the inner assembly 506
(such as, if the inner assembly became stuck in the wellbore), a
sufficient axially upwardly directed force may be applied to the
tubing 526 at the earth's surface to shear the shear pin 552. In
this manner, the outer assembly 518 may be disengaged from the
inner assembly 506 and removed from its outwardly disposed
relationship with the inner assembly, and the inner assembly may be
separately retrieved from the wellbore.
With the apparatus 500 in its extended configuration as shown in
FIG. 9B, an outer polished surface 556 on the upper mandrel 512 is
axially sealingly received in the lower retainer 524. Thus, fluid
flow from the wellbore to the interior 532 of the apparatus 500 is
directed through the screen 502 for screening of sand, debris, etc.
therefrom.
If it is desired to again outwardly surround the screen 502 with
the outer tubular member 504, or to prevent fluid communication
between the interior 532 and the wellbore, the outer assembly 518
may be axially downwardly displaced relative to the inner assembly
506. For prevention of the fluid communication, the outer assembly
518 may be sufficiently downwardly displaced relative to the inner
assembly 506 so that the seals 530 again sealingly engage the lower
mandrel 516.
In a preferred method of using the apparatus 500, the apparatus is
run into the wellbore suspended from the tubing 526, the apparatus
being in its compressed configuration as shown in FIG. 9A. The
tubing 526 and apparatus 500 are lowered until the lower mandrel
516 touches the bottom of the wellbore. The ball 550 is then
dropped through the tubing 526 from the earth's surface and
pressure is applied to the tubing to shear the shear screw 540. The
tubing 526 and outer assembly 518 are then raised, the inner
assembly 506 remaining at the bottom of the wellbore, until the
apparatus 500 is in its extended configuration as shown in FIG. 9B.
In this way, the screen 502 may be run, set, and put into
production in one trip into the wellbore. The screen 502 may be
advantageously run into wellbores of questionable cleanliness and
without concern regarding debris, paraffin, etc. in the wellbores
which might otherwise contaminate or damage the screen.
Note that equipment operatively positionable in the wellbore other
than the screen 506 may be utilized in the apparatus 500. For
example, a perforating gun may be utilized in place of, or in
addition to, the screen 502 in the inner assembly 506.
It is to be understood that, although various embodiments of
apparatus for positioning equipment in a wellbore described
hereinabove which include a release mechanism actuatable by
pressure applied to an inner flow passage above a ball are not also
illustrated as including a latching profile for mechanical
actuation of the release mechanism, such inclusion of a latching
profile in each of the disclosed embodiments is contemplated by the
inventors. An embodiment of the present invention having a release
mechanism which is actuatable by both direct application of force
via a latching tool latched into a latching profile and by
application of pressure after installing a ball is specifically
illustrated in FIGS. 1A and 1B. Therefore, a latching profile for
mechanical actuation of the release mechanism may be included in
each of the above disclosed embodiments without departing from the
principles of the present invention.
The foregoing detailed description is to be clearly understood as
being given by way of illustration and example only, the spirit and
scope of the present invention being limited solely by the appended
claims.
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